Methods and apparatus to operate a gas turbine engine with hydrogen gas

ABSTRACT

Methods and apparatus to operate a gas turbine engine with hydrogen gas are disclosed. An example combustor nozzle apparatus of a gas turbine engine includes injecting an other combustible gas into a combustor, comparing a power output of the gas turbine to a rated power threshold, and in response to the power output of the gas turbine satisfying the rated power threshold: injecting water into the combustor, injecting hydrogen into the combustor, and terminating injections of the other combustible gas.

RELATED APPLICATION

This patent arises from a continuation of U.S. patent application Ser.No. 17/112,615, which was filed on Dec. 4, 2020. U.S. patent applicationSer. No. 17/112,615 is hereby incorporated herein by reference in itsentirety. Priority to U.S. patent application Ser. No. 17/112,615 ishereby claimed.

FIELD OF THE DISCLOSURE

This disclosure relates generally to gas turbine engines, and, moreparticularly, to methods and apparatus to operate a gas turbine enginewith hydrogen gas.

BACKGROUND

In recent years, gas turbine engines have utilized mixtures of hydrogengas and conventional fuels because of the advantages hydrogen gasprovides. Specifically, hydrogen is an abundantly available element thathas beneficial properties for combustion in gas turbine engines, such asreduced carbon emissions, lower fuel consumption (pounds per hour(pph)), greater energy production, light weight, and high combustionrate and temperature. During combustion of the mixture of hydrogen gasand conventional fuels chemical energy and thermal energy are convertedinto mechanical energy. The mechanical energy produced as a result ofthe combustion can drive downstream turbine blades and providepropulsion to an aircraft or drive a shaft of a generator that produceselectric current.

BRIEF SUMMARY

Methods and apparatus to operate a gas turbine engine with hydrogen gasare disclosed.

Certain examples provide an example combustor nozzle apparatus of a gasturbine engine including a first circuit to transport a blend of atleast one of hydrogen gas, inert gas, or other combustible gas from asupply to a gas turbine combustor, the blend of at least one of hydrogengas, inert gas, or other combustible gas including between 100% hydrogengas, 100% inert gas, or 100% other combustible gas, a second circuit totransport water from the supply to the gas turbine combustor during afirst mode of operation, and a nozzle tip. The nozzle tip includes afirst outlet in connection with the second circuit the water to the gasturbine combustor, and a second outlet in connection with the firstcircuit. The second outlet is concentrically positioned within the firstoutlet to provide the blend of at least one of hydrogen gas, inert gas,or other combustible gas to the gas turbine combustor.

Certain examples provide an example method to operate a gas turbineengine with up to 100% hydrogen gas as fuel including purging a gasturbine combustor and a first circuit of a combustor nozzle with aninert gas or an other combustible gas, injecting hydrogen gas into thegas turbine combustor through the first circuit of the nozzle, the firstcircuit including a blend of at least one of hydrogen gas, inert gas, orother combustible gas, wherein the blend of at least one of hydrogengas, inert gas or other combustible gas includes between 100% hydrogengas and 100% inert gas or 100% other combustible gas, injecting waterinto the gas turbine combustor through a second circuit of the combustornozzle, and increasing a percentage of hydrogen gas in the blend of atleast one of hydrogen gas, inert gas, or other combustible gas to up to100% hydrogen gas as the gas turbine engine maintains or increases apower output.

Certain examples provide an example apparatus of a gas turbine engineincluding a memory, and one or more processors communicatively coupledto the memory, the memory including instructions that, when executed,cause the one or more processors to purge a first circuit of a combustornozzle and a gas turbine combustor with an inert gas or an othercombustible gas, inject hydrogen gas into the gas turbine combustorthrough the first circuit of the nozzle, the first circuit of the nozzleincluding a blend of at least one of hydrogen gas, inert gas, or othercombustible gas, the blend of at least one of hydrogen gas, inert gas,or other combustible gas including between 100% hydrogen gas and 100%inert gas or 100% other combustible gas, inject water into the gasturbine combustor through a second circuit of the combustor nozzle, andincrease a percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas to up to 100% hydrogengas as the gas turbine engine maintains or increases a power output.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is an illustration of an example fuel nozzle of an example gasturbine engine.

FIG. 2 is a magnified view of an example fuel nozzle tip of the examplegas turbine engine of FIG. 1.

FIGS. 3A-C illustrate first example fluid blends that flow through theexample fuel nozzle of the example gas turbine engine of FIGS. 1 and/or2.

FIGS. 4A-C illustrate second example fluid blends that flow through theexample fuel nozzle of the example gas turbine engine of FIGS. 1 and/or2.

FIG. 5 is a block diagram of an example combustor controller of theexample gas turbine engine and associated fuel nozzle of FIGS. 1, 2, 3,and/or 4.

FIG. 6 is a block diagram of a first example schematic of the examplefuel nozzle of the example gas turbine engine of FIGS. 1, 2, 3, and/or4.

FIG. 7 is a block diagram of second example schematic of the examplefuel nozzle of the example gas turbine engine of FIGS. 1, 2, 3, and/or4.

FIGS. 8A-C illustrate example fluid blends that flow through analternative example fuel nozzle of the example gas turbine engine.

FIG. 9 is a block diagram of an example schematic of the alternativeexample fuel nozzle of the example gas turbine engine of FIGS. 8A-C.

FIG. 10 is a flowchart representative of machine readable instructionswhich may be executed to implement the example gas turbine engine ofFIGS. 1-9.

FIG. 11 is a flowchart representative of machine readable instructionswhich may be executed to implement a power shut down of the example gasturbine engine of FIGS. 1-10.

FIG. 12 is a block diagram of an example processing platform structuredto execute the instructions of FIGS. 10 and 11 to implement the examplegas turbine engine of FIGS. 1-8.

The figures are not to scale. Although the figures show layers andregions with clean lines and boundaries, some or all of these linesand/or boundaries may be idealized. In reality, the boundaries and/orlines may be unobservable, blended, and/or irregular. In general, thesame reference numbers will be used throughout the drawing(s) andaccompanying written description to refer to the same or like parts. Asused in this patent, stating that any part (e.g., a layer, film, area,region, or plate) is in any way on (e.g., positioned on, located on,disposed on, or formed on, etc.) another part, indicates that thereferenced part is either in contact with the other part, or that thereferenced part is above the other part with one or more intermediatepart(s) located therebetween. As used herein, connection references(e.g., attached, coupled, connected, and joined) may includeintermediate members between the elements referenced by the connectionreference and/or relative movement between those elements unlessotherwise indicated. As such, connection references do not necessarilyinfer that two elements are directly connected and/or in fixed relationto each other. As used herein, stating that any part is in “contact”with another part is defined to mean that there is no intermediate partbetween the two parts.

Unless specifically stated otherwise, descriptors such as “first,”“second,” “third,” etc., are used herein without imputing or otherwiseindicating any meaning of priority, physical order, arrangement in alist, and/or ordering in any way, but are merely used as labels and/orarbitrary names to distinguish elements for ease of understanding thedisclosed examples. In some examples, the descriptor “first” may be usedto refer to an element in the detailed description, while the sameelement may be referred to in a claim with a different descriptor suchas “second” or “third.” In such instances, it should be understood thatsuch descriptors are used merely for identifying those elementsdistinctly that might, for example, otherwise share a same name. As usedherein, “approximately” and “about” refer to dimensions that may not beexact due to manufacturing tolerances and/or other real worldimperfections. As used herein “substantially real time” refers tooccurrence in a near instantaneous manner recognizing there may be realworld delays for computing time, transmission, etc. Thus, unlessotherwise specified, “substantially real time” refers to real time +/−1second.

DETAILED DESCRIPTION

Hydrogen is an abundant fuel source that has additional beneficialproperties for combustion in gas turbine engines, such as a highcombustion rate and temperature, which can increase an efficiency of thegas turbine engine. Gas turbine engines produce power and/or mechanicaldrive for aeronautics, marine applications, gear boxes, off-shore powergenerators, terrestrial power plants, etc. Gas turbine engines canutilize hydrogen gas in addition to other conventional fuels to convertthermal and chemical energy to mechanical energy via combustion.Specifically, a gas turbine engine that utilizes hydrogen gas duringcombustion can incrementally increase a quantity of energy producedcompared to a conventional gas turbine engine that does not utilizehydrogen gas. Further, utilizing hydrogen gas within gas turbine enginesreduces harmful carbon emissions, which is a focus of power producersgiven the emission regulations that have been implemented bylegislation.

In some examples, the greater combustion rate of hydrogen results in ahigher volumetric flow rate of hydrogen gas compared to conventionalfuels. Further, the increased flame temperature resulting from thecombustion of hydrogen gas can increase harmful nitrogen oxide emissionsin addition to increasing a risk of combustion flashback and flameholding in the fuel system. In some examples, combustion flashbackand/or flame holding can cause potential deflagration combustion, whichpresents a catastrophic risk to operators. Further, increased nitrogenoxide emissions are harmful for the environment as the nitrogen oxideemissions react with organic compounds in the atmosphere hindering anability of the ozone layer to protect the planet from harmful radiation.Accordingly, the hinderances and/or risks that result from utilizinghydrogen gas have limited the implementation thereof as fuel in gasturbine engines.

In known implementations, multiple nozzles can be utilized to inducewater and hydrogen gas into the combustor. In some instances, a nozzlethat induces fuel into the combustor includes a chamber for mixing thefuel with water vapor before the fuel is injected into the combustor. Insome examples, a valve is configured to increase a mass flow of hydrogenat low power operations of a turbine and stop injections of hydrogen athigh power operations. In some examples, hydrocarbon fuel is supplied toa combustor at all power operations of the gas turbine engine whilehydrogen gas is induced at low-power operations and terminated atmid-power and high-power operations. In some examples, hydrogen fuel isutilized in a fuel blend in combination with liquefaction gas, naturalgas, and/or coal gas. In some examples, hydrogen fuel accounts for up to75% of the fuel blend at predetermined power operations. However, highervolumes of hydrogen gas increases risks such as combustion flashback,flame holding, increased nitrogen oxide emissions, and deterioration inthe gas turbine engine. As such, achieving an increased mix or usage ofhydrogen fuel is problematic, if not impossible, using prior techniques.

Example methods and apparatus to operate a gas turbine engine withhydrogen gas are disclosed herein. In some examples, the gas turbineengine includes a combustor nozzle at least partially including a firstcircuit and a second circuit. In some examples, the first circuittransports a blend of at least one of hydrogen gas, inert gas (e.g.,nitrogen gas, carbon dioxide, etc.), or other combustible gas (e.g.,methane, propane, natural gas, etc.) from a supply to a gas turbinecombustor. As used herein, the term “other combustible gas” refers to acombustible gas that is not hydrogen gas. For example, “othercombustible gas” refers to any of methane, propane, natural gas, and/orany other gas that is combustible and includes other elements inaddition to, or instead of, hydrogen. In some such examples, the blendof at least one of hydrogen gas, inert gas, or other combustible gasranges between 100% hydrogen gas, 100% inert gas, or 100% othercombustible gas. Additionally, the second circuit transports water ormethane from the supply to the gas turbine combustor. In some suchexamples, the second circuit transports water during a first mode ofoperation and methane during a second mode of operation so the water andmethane do not mix in the second circuit. In some examples, the firstmode of operation corresponds to the first circuit transporting thehydrogen gas. Further, the second mode of operation corresponds to thefirst circuit transporting gases other than the hydrogen gas. In someexamples, the first and second circuit include one or more flow paths totransport the hydrogen gas, inert gas, other combustible gas, water, ormethane from the supply to the gas turbine combustor.

Further, the combustor nozzle includes a nozzle tip with a first outlet,a second outlet, and a third outlet. In some examples, the first outletprovides air flow to the gas turbine combustor. In some such examples,the first outlet includes an air swirler to mix the water or methanewith the blend of at least one of hydrogen gas, inert gas, or othercombustible gas. In some examples, the second outlet of the nozzle tipis in connection with the second circuit of the combustor nozzle. Insome such examples, the second outlet is concentrically positionedwithin the first outlet to provide the water or methane to the gasturbine combustor. In other words, the first outlet circumferentiallysurrounds the second outlet. Additionally, the second outlet includes awater swirler to reduce a size of water droplets as they are inducedinto the gas turbine combustor. In some examples, at least one of theair swirler or the water swirler quenches a temperature within the gasturbine combustor. In some examples, the third outlet is in connectionwith the first circuit of the combustor nozzle. In some such examples,the third outlet is concentrically positioned within the second outletto provide the blend of at least one of hydrogen gas, inert gas, orother combustible gas to the gas turbine combustor. In other words, thesecond outlet concentrically surrounds the third outlet. In someexamples, an alternative nozzle can be utilized instead of the examplecombustor nozzle described above to operate the gas turbine engine withup to 100% hydrogen gas. In some examples, a nozzle includes threeindependent circuits that are configured to operate similar to the firstand second circuits of the example combustor nozzle.

In some examples, a combustor controller is in communication with fuelmetering valves associated with the combustor nozzle to control theblend of at least one of hydrogen gas, inert gas, or other combustiblegas transported through the first circuit and the water or methanetransported through the second circuit. In some examples, prior toinjecting hydrogen gas into the gas turbine combustor through the firstcircuit of the combustor nozzle, the combustor controller purges thefirst circuit of the combustor nozzle and the gas turbine combustor withthe inert gas or the other combustible gas. As used herein, the term“purge” encompasses deoxygenating a system and removing residual gases,such as hydrogen gas, from the system. Advantageously, the purge of thefirst circuit of the combustor nozzle and the gas turbine combustorprevents undesired combustion, such as combustion flashback and/or flameholding, that occurs when excess hydrogen gas and/or oxygen remain inthe gas turbine engine.

In some examples, the combustor controller injects the inert gas and/orthe other combustible gas through the first circuit and methane (e.g.,natural gas) through the second circuit to accelerate the gas turbineengine to a synchronized idle speed. In some examples, the othercombustible gas accelerates the gas turbine engine to the synchronizedidle speed while purging so methane does not need to be injected throughthe second circuit. In some examples, the gas turbine engine operates at10% of a rated power thereof at the synchronized idle speed. In someexamples, the gas turbine engine circuit breaker is closed so the gasturbine engine can accept a load after accelerating to the synchronizedidle speed. Further, the combustor controller injects water into the gasturbine combustor through the second circuit and injects hydrogen gasinto the gas turbine combustor through the first circuit directly afterwater is induced into the gas turbine combustor. Accordingly, thecombustor controller terminates injections of methane through the secondcircuit prior to inducing water so the water and methane do not mix. Insome examples, the water manages the flame within the combustor toreduce a temperature thereof and, in turn, reduce nitrogen oxideemissions. Additionally, the water provides a thermal barrier betweenthe flame within the combustor and hardware associated with thecombustor to maintain a reliability and durability thereof. In someexamples, the combustor controller increases a percentage of hydrogengas in the blend of at least one of hydrogen gas, inert gas, or othercombustible gas in the first circuit and simultaneously a volumetricflow rate of water increases in the second circuit as a power outputand/or load of the gas turbine is maintained or increases. In some suchexamples, the gas turbine engine can operate with 100% hydrogen gas asfuel at a power output as low as 10% of the rated power and as high as100% of the rated power.

In some examples, water reduces a temperature of a flame in the gasturbine combustor. In some such examples, the water provides the gasturbine combustor with nitrogen oxide emission abatement, flamemanagement, and thermal protection to hardware associated with the gasturbine combustor. Specifically, water provides a thermal barrierbetween the hydrogen gas and the hardware associated with the combustorand/or the combustor nozzle to maintain the reliability and durabilityof the gas turbine engine. Additionally, utilizing a percentage of up to100% hydrogen gas as fuel produces reduced carbon emissions, a lowerfuel consumption, and a higher quantity of energy for the gas turbineengine compared to conventional jet engines.

FIG. 1 is an illustration of a fuel nozzle (e.g., a combustor nozzle)104 of a gas turbine engine 100. In FIG. 1, the fuel nozzle 104 includesa nozzle body 106, a first circuit (e.g., an inside circuit) 108, asecond circuit (e.g., an outside circuit) 110, and a nozzle tip 116. InFIG. 1, the nozzle tip 116 includes a first outlet 118, a second outlet120, and a third outlet 122. In FIG. 1, the gas turbine engine 100further includes a circuit breaker 101, a combustor controller 102, afuel metering valve(s) 103, an engine case 112, and a combustor 114.

In the illustrated example of FIG. 1, a configuration of the circuitbreaker 101 controls a load that the gas turbine engine 100 supports.For example, the circuit breaker 101 remains open to prevent the gasturbine engine 100 from encountering loads during initial stages ofoperation (e.g., prior to accelerating to a synchronized idle speed).Further, the circuit breaker 101 closes to impart loads on the gasturbine engine 100 after accelerating to the synchronized idle speed.

In the illustrated example of FIG. 1, the combustor controller 102controls a blend of at least one of hydrogen gas, inert gas or othercombustible gas transported through the first circuit 108. Additionally,the combustor controller 102 controls water or methane transportedthrough the second circuit 110. In FIG. 1, the combustor controller 102is in communication with the fuel metering valve(s) 103 to control theblend of at least one of hydrogen gas, inert gas, or other combustiblegas and the water or methane transported through the first and secondcircuits 108, 110. In some examples, the fuel metering valve(s) 103includes a hydrogen gas valve, an inert gas valve (e.g., a cardondioxide valve, a nitrogen gas valve, etc.), an other combustible gasvalve, a methane valve, and/or a water valve. In some examples, thecombustor controller 102 determines a composition of the blend (e.g., aratio of hydrogen gas to inert gas and/or other combustible gas) and avolumetric flow rate of water or methane based on a power output and/orload of the gas turbine engine 100. For example, the circuit breaker 101closes and triggers the combustor controller 102 to terminate injectionsof methane though the second circuit 110 and induce water through thesecond circuit 110. Further, the combustor controller 102 adjusts thecomposition of the blend of at least one of hydrogen gas, inert gas, orother combustible gas after the gas turbine engine 100 accelerates tothe synchronized idle speed. In some examples, the combustor controller102 opens, closes, and/or modulates a position of the fuel meteringvalve(s) 103 to transport the blend of at least one of hydrogen gas,inert gas, or other combustible gas and water or methane to the fuelnozzle 104 and the combustor 114.

In the illustrated example of FIG. 1, the gas turbine engine 100 startsoperations with a purge to remove residual gases and provide protectionfrom undesired combustion. In some examples, the other combustible gaspurges the fuel nozzle 104 and the combustor 114 while also acceleratingthe gas turbine engine 100 to the synchronized idle speed. Further,after reaching the synchronized idle speed, the circuit breaker 101closes to allow the gas turbine engine 100 to safely accept loads andprovide a steady thrust. For example, if the gas turbine engine 100 wereto accept loads prior to reaching the synchronized idle speed, the fuelnozzle 104 and/or combustor 114 would not include a sufficient volume ofthe blend of at least one of hydrogen gas, inert gas, or othercombustible gas which could result in operational control challenges,such as a stalled gas turbine engine 100. In some examples, thecombustor controller 102 determines the fuel nozzle 104 and/or combustor114 are sufficiently filled with the other combustible gas and/or theinert gas at the synchronized idle speed and initiates hydrogen gasinjections without risking undesired combustion. Further, a percentageand/or volume of hydrogen gas safely ranges from 0% to 100% when thefuel nozzle 104 and/or combustor 114 have been purged and aresufficiently filled with the blend of at least one of hydrogen gas,inert gas, or other combustible gas. In some examples, a high percentageof hydrogen gas is injected into the gas turbine engine 100 while thegas turbine engine 100 operates anywhere between 10% and 100% ratedpower to reduce nitrogen oxide emissions.

In the illustrated example of FIG. 1, the nozzle body 106 is coupled tothe engine case 112. In FIG. 1, the first circuit 108 of the fuel nozzle104 induces the blend of at least one of hydrogen gas, inert gas, orother combustible gas into the combustor 114. In FIG. 1, the secondcircuit 110 of the fuel nozzle 104 induces the water or methane into thecombustor 114. In FIG. 1, the first outlet 118 of the nozzle tip 116provides air flow into the combustor 114. In some examples, the secondoutlet 120 of the nozzle tip 116 is in connection with the secondcircuit 110 of the fuel nozzle 104 to provide the water or methane tothe combustor 114 based on the mode of operation. In some such examples,the second outlet 120 is positioned concentrically within the firstoutlet 118. In some examples, the third outlet 122 is in connection withthe first circuit 108 to provide the blend of at least one of hydrogengas, inert gas, or other combustible gas to the combustor 114. In somesuch examples, the third outlet 122 is positioned concentrically withinthe second outlet 120.

In the illustrated example of FIG. 1, the combustor controller 102starts the gas turbine engine 100 by opening a methane valve (e.g., anatural gas valve) of the fuel metering valve(s) 103 to inject methanethrough the second circuit 110 and into the combustor 114. In theillustrated example of FIG. 1, the combustor controller 102 opens aninert gas valve and/or an other combustible gas valve of the fuelmetering valve(s) 103 to inject the inert gas and/or other combustiblegas through the first circuit 108 as the gas turbine engine 100accelerates to a synchronized idle speed. In some such examples, theinert gas and/or other combustible gas purges the first circuit 108 andthe combustor 114 prior to inducing the hydrogen gas. Specifically,purging the first circuit 108 and the combustor 114 removes residualhydrogen gas and deoxygenates the gas turbine engine 100 to preventundesired combustion. In some examples, nitrogen gas, which has arelatively low cost of procurement compared to other gases, isimplemented as the inert gas to purge the first circuit 108 and thecombustor 114. In some examples, carbon dioxide is implemented as theinert gas that purges the first circuit 108 and the combustor 114.

In the illustrated example of FIG. 1, the gas turbine engine 100 circuitbreaker 101 is closed after the gas turbine engine 100 accelerates tothe synchronized idle speed so the gas turbine engine 100 can acceptloads. In some examples, purging the first circuit 108 and the combustor114 with the other combustible gas can speed up the process ofaccelerating the gas turbine engine 100 to the synchronized idle speed.In the illustrated example of FIG. 1, after the circuit breaker 101 ofthe gas turbine engine 100 is closed, the combustor controller 102closes the methane valve to terminate injections of methane through thesecond circuit 110. Further, the combustor controller 102 opens a watervalve of the fuel metering valve(s) 103 to transport water into thecombustor 114 via the second circuit 110. Further, the combustorcontroller 102 opens a hydrogen valve of the fuel metering valve(s) 103to induce hydrogen gas into the combustor 114 through the first circuit108 after water is induced into the combustor 114.

In the illustrated example of FIG. 1, the combustor controller 102further opens the hydrogen valve and begins closing the inert gas valveor the other combustible gas valve of the fuel metering valve(s) 103 toincrease a percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas transported into thecombustor 114 through the first circuit 108. In some examples, thecombustor controller 102 further opens the water valve to increase avolumetric flow rate of water injected into the second circuit 110 andthe combustor 114. In some examples, the percentage of hydrogen gas inthe first circuit 108 can increase to up to 100% hydrogen gas as the gasturbine engine 100 operates at, or between, 10% and/or 100% of the ratedpower. In some such examples, the volumetric flow rate of water in thesecond circuit 110 increases as the percentage of hydrogen gas increasesin the blend of at least one of hydrogen gas, inert gas, or othercombustible gas and/or the power output of the gas turbine engineincreases.

In the illustrated example of FIG. 1, to reduce power and/or shut downthe gas turbine engine 100, the combustor controller 102 closes thehydrogen valve of the fuel metering valve(s) 103 to decrease thepercentage of hydrogen gas in the blend of at least one of hydrogen gas,inert gas, or other combustible gas transported through the firstcircuit 108 as the power output and/or load of the gas turbine engine100 decreases. Further, the combustor controller 102 closes the watervalve of the fuel metering valve(s) 103 to decrease the volumetric flowrate of water transported through the second circuit 110. In someexamples, the combustor controller 102 opens the circuit breaker 101before re-purging the first circuit 108 of the fuel nozzle 104 and thecombustor 114 with the inert gas. In some such examples, the gas turbineengine 100 does not accept loads while re-purging and/or preparing topower down. In some examples, water purges the combustor 114 in responseto the inert gas supply being depleted. In the illustrated example ofFIG. 1, the gas turbine engine 100 can power down after the firstcircuit 108 and the combustor 114 have been re-purged. In some examples,the combustor controller 102 shuts down the gas turbine engine 100 whena hydrogen gas supply is depleted. In some such examples, the combustorcontroller 102 compares the hydrogen gas supply to a minimum thresholdsupply of the hydrogen gas to determine if the gas turbine engine 100 isto shut down.

FIG. 2 is a magnified view 200 of the fuel nozzle tip 116 in connectionwith the combustor 114 of the gas turbine engine 100 of FIG. 1. In theillustrated example, the fuel nozzle tip 116 includes the first outlet118, the second outlet 120, and the third outlet 122 of FIG. 1. In FIG.2, the fuel nozzle tip 116 further includes an air swirler 202positioned within the first outlet 118 and a water swirler 204positioned within the second outlet 120.

In the illustrated example of FIG. 2, the air swirler 202 mixes thewater or methane with the blend of at least one of hydrogen gas, inertgas, or other combustible gas. In some such examples, the air swirler202 provides an advantageous atomization of the gases to enhance acapability of the combustor 114 to burn the methane, hydrogen, and/orother combustible gas. Further, the air swirler 202 provides air flowinto the combustor 114. In the illustrated example of FIG. 2, the waterswirler 204 reduces (e.g., minimizes) a size of water droplets andprovides the water with turbulence to mix with the blend of at least oneof hydrogen gas, inert gas, or other combustible gas. In some examples,the water swirler 204 disperses the water to quench a temperature withinthe combustor 114. Accordingly, the water provides the gas turbineengine 100 with thermal protection by providing a thermal barrierbetween the hydrogen gas and hardware associated with fuel nozzle 104and/or the combustor 114. In some such examples, the air swirler 202and/or the water swirler 204 enhance a capability and/or durability ofthe combustor 114 and, in turn, the gas turbine engine 100.

FIGS. 3A-C illustrate example fluid blends that flow through the fuelnozzle 104 of the gas turbine engine 100 of FIGS. 1 and/or 2.Specifically, FIGS. 3A-C illustrate operating phases of the blend of atleast one of hydrogen gas, inert gas, or other combustible gastransported through the first circuit 108 and the water or methanetransported through the second circuit 110 in accordance with operationsof the gas turbine engine 100. FIG. 3A illustrates example fluid blendsthat flow through the fuel nozzle 104 to start and accelerate the gasturbine engine 100 to a synchronized idle speed (e.g., a grid stabilizedspeed, a part power condition, etc.). In the illustrated example of FIG.3A, the gas turbine engine 100 is started with the blend of at least oneof hydrogen gas, inert gas, or other combustible gas transported throughthe first circuit 108 and methane 302 transported through the secondcircuit 110. In FIG. 3A, methane 302 is implemented as the blend of atleast one of hydrogen gas, inert gas, or other combustible gastransported through the first circuit 108. In FIG. 3A, methane 302purges the first circuit 108 and accelerates the gas turbine engine 100to the synchronized idle speed. In some examples, methane 302 is onlyinjected through the first circuit 108 to accelerate the gas turbineengine 100 to the synchronized idle speed. In some examples, an inertgas, such as nitrogen or carbon dioxide, purges the first circuit 108instead of methane 302, as discussed further in association with FIG.4A. In FIG. 3A, methane 302 is also transported through the secondcircuit 110 to accelerate the gas turbine engine 100 to the synchronizedidle speed.

In the illustrated example of FIG. 3B, the circuit breaker 101 of thegas turbine engine 100 is closed so the gas turbine engine 100 canaccept loads. In FIG. 3B, injections of methane 302 through the secondcircuit 110 are terminated. In FIG. 3B, water 304 is induced into thecombustor 114 through the second circuit 110. In FIG. 3B, water 304 isinduced into the combustor 114 prior to inducing hydrogen gas to managethe flame within the combustor 114, provide nitrogen oxide emissionsabatement, and/or protect hardware associated with the combustor 114.Specifically, water 304 cools down a temperature of the flame within thecombustor 114 to reduce nitrogen oxide emissions. Additionally oralternatively, the water 304 provides a thermal barrier between theflame of the combustor 114 and hardware associated with the combustor114.

In the illustrated example of FIG. 3B, hydrogen gas is induced into thecombustor 114 through the first circuit 108 to provide a mixture ofhydrogen gas and methane 306. In other words, the blend of at least oneof hydrogen gas, inert gas, or other combustible gas transitions frommethane 302 to the mixture of hydrogen gas and methane 306. In theillustrated example of FIG. 3B, a percentage of hydrogen gas in themixture of hydrogen gas and methane 306 and a volumetric flow rate ofwater 304 simultaneously increase to maintain or increase the poweroutput of the gas turbine engine 100.

In the illustrated example of FIG. 3C, hydrogen gas 310 is transportedinto the combustor 114 through the first circuit 108 and water 308 istransported into the combustor 114 through the second circuit 110. Forexample, the mixture of hydrogen gas and methane 306 transitions tohydrogen gas 310. In the illustrated example, the gas turbine engine 100operates with the hydrogen gas 310 as fuel while the water 304 reduces atemperature of a flame within the combustor 114 and protects hardwareassociated with the combustor 114. In some such examples, the gasturbine engine 100 can operate at up to 100% rated power. In someexamples, utilizing hydrogen gas 310 as fuel instead of otherhydrocarbons, such as methane, reduces carbon emissions of the gasturbine engine 100.

FIGS. 4A-C illustrate additional and/or alternative fluid blends thatflow through the fuel nozzle 104 of the gas turbine engine 100 of FIGS.1 and/or 2. Specifically, FIGS. 4A-C illustrate operating phases of theblend of at least one of hydrogen gas, inert gas, or other combustiblegas transported through the first circuit 108 and the water or methanetransported through the second circuit 110 in accordance with operationsof the gas turbine engine 100. In the illustrated example of FIG. 4A,methane (e.g., natural gas) 302 is transported through the secondcircuit 110 to start and accelerate the gas turbine engine 100 to thesynchronized idle speed. In FIG. 4A, nitrogen gas 402 is implemented asthe blend of at least one of hydrogen gas, inert gas, or othercombustible gas transported through the first circuit 108. Specifically,nitrogen gas 402 purges the first circuit 108 and the combustor 114prior to inducing hydrogen gas to prevent undesired combustion in thegas turbine engine 100. In some alternative examples, carbon dioxide isimplemented as the blend of at least one of hydrogen gas, inert gas, orother combustible gas to purge the first circuit 108 and the combustor114 instead of, or in addition to, nitrogen gas 402.

In the illustrated example of FIG. 4B, the gas turbine engine 100 hasaccelerated to the synchronized idle speed and the associated circuitbreaker 101 is closed so the gas turbine engine 100 can accept loads. InFIG. 4B, injections of methane 302 through the second circuit 110 areterminated. In FIG. 4B, water 304 is induced into the combustor 114through the second circuit 110. In FIG. 4B, hydrogen gas is induced intothe combustor 114 through the first circuit 108 to provide a mixture ofnitrogen gas and hydrogen gas 404 to the combustor 114. In other words,the blend of at least one of hydrogen gas, inert gas, or othercombustible gas transitions from nitrogen gas 402 to the mixture ofnitrogen gas and hydrogen gas 404. In the illustrated example of FIG.4B, a percentage of hydrogen gas in the mixture of nitrogen gas andhydrogen gas 404 and a volumetric flow rate of water 304 simultaneouslyincrease to maintain or increase a power output of the gas turbineengine 100.

In the illustrated example of FIG. 4C, hydrogen gas 310 is transportedinto the combustor 114 through the first circuit 108 and water 304 istransported into the combustor 114 through the second circuit 110. Inother words, the blend of at least one of hydrogen gas, inert gas, orother combustible gas transitions from the mixture of nitrogen gas andhydrogen gas 404 to hydrogen gas 310. In FIG. 4C, the gas turbine engine100 operates with hydrogen gas 310 as fuel and water 308 manages theflame within the combustor 114 to quench a temperature within thecombustor, provide nitrogen oxide emissions abatement, and/or protecthardware associated with the combustor 114. In FIG. 4C, the gas turbineengine 100 can operate with a power output at, or between, 10% and 100%rated power.

FIG. 5 is a block diagram 500 of the combustor controller 102 of the gasturbine engine 100 of FIGS. 1, 2, and/or 3. In the illustrated exampleof FIG. 5, the combustor controller 102 includes a stage manager 504, afirst circuit controller (e.g., an inside circuit controller) 506, and asecond circuit controller (e.g., an outside circuit controller) 508. InFIG. 5, the inside circuit controller 506 includes an other combustiblegas injection processor 510, an inert gas injection processor 512, and ahydrogen gas injection processor 514. In FIG. 5, the outside circuitcontroller 508 includes a methane (e.g., natural gas) injectionprocessor 516, and a water injection processor 518. The block diagram500 further includes the circuit breaker 101, an engine power processor502 and the fuel metering valve(s) 103 in communication with thecombustor controller 102.

In the illustrated example of FIG. 5, the combustor controller 102receives a power output, a load, and/or an operating frequency of thegas turbine engine 100 from the engine power processor 502. For example,the engine power processor 502 can determine the power output of the gasturbine engine 100 in megawatts (MW). Additionally, the engine powerprocessor 502 can determine an operating frequency of the gas turbineengine 100 in revolutions per minute (rpm) and/or Hertz (Hz). In someexamples, the engine power processor 502 determines and/or controlsother parameters, such as a temperature, pressure, fuel flow, etc., ofthe gas turbine engine 100. Further, the engine power processor 502communicates the power output, load, and/or operating frequency of thegas turbine engine 100 to the combustor controller 102. In FIG. 5, thecircuit breaker 101 indicates a configuration thereof to the combustorcontroller 102. In FIG. 5, the combustor controller 102 controls theblend of at least one of hydrogen gas, inert gas, or other combustiblegas transported through the first circuit (e.g., the inside circuit) 108and a volumetric flow of the water or methane transported through thesecond circuit (e.g., the outside circuit) 110 to control the poweroutput of the gas turbine engine 100 based on communications with thecircuit breaker 101 and the engine power processor 502.

In the illustrated example of FIG. 5, the stage manager 504 of thecombustor controller 102 compares the power output and/or load of thegas turbine engine 100 determined by the engine power processor 502 to arated power and/or operating frequency capability of the gas turbineengine 100. In FIG. 5, the stage manager 504 determines a stage ofoperation of the gas turbine engine 100 based on the comparison betweenthe power output and/or the operating frequency of the gas turbineengine 100 and the rated power and/or maximum operating frequency of thegas turbine engine 100. In some examples, the stage manager 504determines the stage of operation of the gas turbine engine 100 based onthe configuration of the circuit breaker 101.

In the illustrated example of FIG. 5, the stage manager 504 determinesthat the gas turbine engine 100 is operating at the synchronized idlespeed when the circuit breaker 101 is closed. In some examples, thestage manager 504 determines that the gas turbine engine 100 isoperating at a synchronized idle speed (e.g., synchronized to the grid)when the power output is approximately 10% of the rated power and/orwhen the operating frequency of the gas turbine engine 100 reachesapproximately 50 Hz. For example, when the rated power of the gasturbine engine 100 is 50 MW, the stage manager 504 determines that thegas turbine engine 100 is operating at the synchronized idle speed whenthe power output determined by the engine power processor 502 is greaterthan or equal to 5 MW. In some examples, the engine power processor 502indicates to the combustor controller 102 that the gas turbine engine100 has closed the circuit breaker 101 to accept loads when the gasturbine engine 100 is operating at the synchronized idle speed. In someexamples, the gas turbine engine 100 utilizes up to 100% hydrogen gas asfuel after closing the circuit breaker 101 to accept loads.

In the illustrated example of FIG. 5, the stage manager 504 inverts theoperating stages to shut down the gas turbine engine 100. In someexamples, a shutdown indication is communicated to the combustorcontroller 102 via a user interface, a sensor associated with thesupply, etc. In some examples, the engine power processor 502 providesan emergency shut down indication to the combustor controller 102 inwhich case the stage manager 504 determines that the gas turbine engine100 is to terminate operations (e.g., power down). For example, when thegas turbine engine 100 has a depleted supply of hydrogen gas, anemergency shutdown can occur. Further, the shutdown indication from theengine power processor 502 can indicate if the shutdown is to occur insubstantially real time or over a period of time. In some examples, thegas turbine engine 100 reduces power and opens the circuit breaker 101so the gas turbine engine 100 cannot accept a load. In some examples,the combustor controller 102 purges the gas turbine engine 100 after thecircuit breaker opens and before the gas turbine engine 100 powers down.

In the illustrated example of FIG. 5, the stage manager 504 is incommunication with the first circuit controller 506 and the secondcircuit controller 508. In FIG. 5, the first circuit controller 506determines the blend to be transported through the first circuit 108 andthe second circuit controller 508 determines a volume of water ormethane to be transported through the second circuit 110 based on thedetermined stage of operation of the gas turbine engine 100.

In the illustrated example of FIG. 5, the stage manager 504 provides apurge indication to the first circuit controller 506 when the gasturbine engine 100 is operating within the initial power stage. In someexamples, the inert gas injection processor 512 determines that anassociated inert gas (e.g., nitrogen, carbon dioxide, etc.) is to purgethe first circuit 108 and the combustor 114 in response to the firstcircuit controller 506 receiving the purge indication. In some examples,the other combustible gas injection processor 510 determines that anassociated other combustible gas (e.g., methane, propane, etc.) is topurge the first circuit 108 and the combustor 114 in response to theinside circuit controller 506 receiving the purge indication.

Further, the combustor controller 102 controls the inert gas or othercombustible gas that is to be induced into the combustor 114 via thefuel metering valve(s) 103. In some examples, the combustor controller102 triggers an inert gas valve and/or an other combustible gas valve ofthe fuel metering valve(s) 103 to open and, thus, induce the inert gasand/or other combustible gas into the first circuit 108. In turn, thefuel nozzle 104 injects the inert gas and/or other combustible gas intothe combustor 114.

Additionally, the stage manager 504 provides an initial power indicationto the second circuit controller 508 when the gas turbine engine 100 isoperating within the initial power stage. In FIG. 5, the methaneinjection processor 516 determines that methane is to be induced intothe second circuit 110 and the combustor 114 in response to the secondcircuit controller 508 receiving the initial power indication. Further,the combustor controller 102 triggers the fuel metering valve(s) 103 toinduce methane into the combustor 114 through the second circuit 110. Insome examples, the combustor controller 102 opens a methane valve of thefuel metering valve(s) 103 and, in turn, injects methane into the secondcircuit 110. In turn, the fuel nozzle 104 injects the methane into thecombustor 114. In other examples, the other combustible gas injectedthrough the first circuit 110 accelerates the gas turbine engine 100 tothe synchronized idle speed. In such examples, the methane does not needto be induced into the combustor through the second circuit 110.

In the illustrated example of FIG. 5, the stage manager 504 provides aclosed circuit breaker 101 indication to the first circuit controller506 and the second circuit controller 508 when the engine powerprocessor 502 indicates that the gas turbine engine 100 is operating atthe synchronized idle speed and supporting a load. In FIG. 5, the waterinjection processor 518 determines that water is to be induced into thecombustor 114 in response to the second circuit controller 508 receivingthe closed circuit breaker 101 indication. Additionally, the hydrogengas injection processor 514 determines that hydrogen gas is to beinduced into the combustor 114 in response to the first circuitcontroller 506 receiving the closed circuit breaker 101 indication.

Further, the combustor controller 102 controls the fuel meteringvalve(s) 103 to induce through water the second circuit 110 followed byhydrogen gas through the first circuit 108. Specifically, the combustorcontroller 102 opens a water valve in connection with the second circuit110 followed by a hydrogen valve in connection with the first circuit108 to induce water and hydrogen gas into the combustor 114. In FIG. 5,the water is induced prior to the hydrogen gas to manage the flamewithin the combustor 114 and provide nitrogen oxide emissions abatement.In FIG. 5, injections of methane through the second circuit 110 areterminated prior to inducing the water.

In the illustrated example of FIG. 5, the first circuit controller 506increases a percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas. Specifically, thehydrogen gas injection processor 514 indicates an increasing volume ofhydrogen gas to be induced into the first circuit 108 to the combustorcontroller 102. In some examples, the inert gas injection processor 512or the other combustible gas injection processor 510 indicates to thecombustor controller 102 a decreasing volume of inert gas or othercombustible gas to be induced into the first circuit 108 in combinationwith the increasing volume of hydrogen gas. In FIG. 5, the combustorcontroller 102 triggers the fuel metering valve(s) 103 to close (e.g.,partially close, fully close, etc.) an inert gas valve or an othercombustible gas valve and simultaneously open (e.g., partially open,fully open, etc.) a hydrogen gas valve. In turn, the fuel nozzle 104injects the blend of at least one of hydrogen gas, inert gas, or othercombustible gas through the first circuit 108 into the combustor 114.

In FIG. 5, the water injection processor 518 indicates an increasingvolume of water to be induced through the second circuit 110 to thecombustor controller 102 in response to the second circuit controller508 receiving the closed circuit breaker 101 indication. In FIG. 5, thecombustor controller 102 triggers the fuel metering valve(s) 103 tofully close a methane valve and open (e.g., partially open, fully open,etc.) a water valve in response to methane being cleared from the secondcircuit 110.

In the illustrated example of FIG. 5, the combustor controller 102increases the percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas induced through thefirst circuit 108 to up to 100% hydrogen gas after the circuit breaker101 is closed. In some such examples, the gas turbine engine 100 canoperate with 100% hydrogen gas as fuel when the power output of the gasturbine engine 100 is greater than or equal to 10% of the rated power ofthe gas turbine engine 100. In FIG. 5, the combustor controller 102increases the volumetric flow rate of water transported into thecombustor 114 through the second circuit 110 after the circuit breaker101 is closed. Further, a volume of the blend of at least one ofhydrogen gas, inert gas, or other combustible gas and/or the volumetricflow rate of water induced into the combustor 114 is based on the poweroutput of the gas turbine engine 100. For example, the volume of theblend of at least one of hydrogen gas, inert gas, or other combustiblegas and the volume of water induced into the combustor 114 increase asthe power output of the gas turbine engine 100 increases.

In the illustrated example of FIG. 5, the combustor controller 102 shutsdown the gas turbine engine 100 by inverting the process of adjustingthe blend of at least one of hydrogen gas, inert gas, or othercombustible gas transported through the first circuit 108 and the wateror methane transported through the second circuit 110. In some examples,the combustor controller 102 reduces the volume of the blend of at leastone of hydrogen gas, inert gas, or other combustible gas and the volumeof water induced into the combustor 114. In some examples, the combustorcontroller 102 reduces the percentage of hydrogen gas in the blend of atleast one of hydrogen gas, inert gas, or other combustible gas. In someexamples, the combustor controller 102 opens the circuit breaker 101 andterminates injections of hydrogen gas as the power output of the gasturbine engine 100 reaches approximately 10% of the rated power. In somesuch examples, the combustor controller 102 purges the first circuit 108and the combustor 114 with the inert gas to prevent undesiredcombustion. Further, the combustor controller 102 triggers the fuelmetering valve(s) 103 to gradually terminate injections after the firstcircuit 108 and the combustor 114 have been purged.

In the illustrated example of FIG. 5, during an emergency shutdownand/or a loss of hydrogen gas supply of the gas turbine engine 100, thestage manager 504 provides a shutdown indication to the first circuitcontroller 506 and the second circuit controller 508. In some examples,the hydrogen gas injection processor 514 indicates a supply of hydrogengas is depleted to the combustor controller 102 and the gas turbineengine 100 is to power down. In FIG. 5, the hydrogen gas injectionprocessor 514 of the first circuit controller 506 indicates thathydrogen injections are to be terminated to the combustor controller102. In some examples, the combustor controller 102 triggers the circuitbreaker 101 to open so the gas turbine engine 100 does not accept loadsin response to the supply of hydrogen gas being depleted. Additionally,the inert gas injection processor 512 indicates to the combustorcontroller 102 that the inert gas is to be induced to purge the firstcircuit 108 and the combustor 114. Further, the combustor controller 102triggers the fuel metering valve(s) 103 to terminate injections ofhydrogen gas and induce the inert gas into the combustor 114. Forexample, the combustor controller 102 closes a hydrogen valve and atleast partially opens an inert gas valve of the fuel metering valve(s)103.

FIG. 6 is a block diagram of a schematic 600 of the fuel nozzle 104 ofthe gas turbine engine 100 of FIGS. 1, 2, 3, and/or 4. In theillustrated example, the fuel nozzle 104 includes at least a portion ofthe first and the second circuits 108, 110. In FIG. 6, the first circuitcontroller 506 is in communication with a hydrogen gas valve 602, aninert gas valve 604, and an other combustible gas valve 606. Further,the second circuit controller 508 is in communication with a methane(e.g., natural gas) valve 608 and a water valve 610. In some examples,the hydrogen gas valve 602, the inert gas valve 604, the othercombustible gas valve 606, the methane valve 608, and/or the water valve610 are positioned between a supply and the first or second circuit 108,110. In FIG. 6, the hydrogen gas valve 602, the inert gas valve 604, andthe other combustible gas valve 606 are in connection with the firstcircuit 108. Further, the methane valve 608 and the water valve 610 arein connection with the second circuit 110.

In the illustrated example of FIG. 6, the first circuit controller 506controls the blend of at least one of hydrogen gas, inert gas, or othercombustible gas transported through the first circuit 108. Specifically,the first circuit controller 506 controls a position of the hydrogen gasvalve 602, the inert gas valve 604, and/or the other combustible gasvalve 606 to control the blend of at least one of hydrogen gas, inertgas, or other combustible gas. In some examples, the first circuitcontroller 506 adjusts a position of the hydrogen valve 602, the inertgas valve 604, and/or the other combustible gas valve 606 to adjust acomposition of the blend of at least one of hydrogen gas, inert gas, orother combustible gas. For example, the first circuit controller 506 canopen the inert gas valve 604 or the other combustible gas valve 606 topurge the first circuit 108. Further, the first circuit controller 506can open the hydrogen gas valve 602 at a rate and close the inert gasvalve 604 or other combustible gas valve 606 at the same rate, or adifferent rate, to transition the gas turbine engine 100 to operate withhydrogen gas as fuel.

In the illustrated example of FIG. 6, the second circuit controller 508controls the water or methane transported through the second circuit110. In some examples, the second circuit controller 508 adjusts aposition of the methane valve 608 and/or the water valve 610.Specifically, the second circuit controller 508 controls a position ofthe methane valve 608 and the water valve 610 to inject water or methaneinto the combustor 114. For example, the second circuit controller 508can open the methane valve 608 to accelerate the engine to asynchronized idle speed. Further, the second circuit controller 508 canclose the methane valve 608 and open the water valve 610 as the gasturbine engine 100 transitions to operate with hydrogen gas as fuel. Insome examples, the gas turbine engine 100 operates with hydrogen gas asfuel with a power output between 10% and 100% rated power.

FIG. 7 is a block diagram of another example schematic 700 of theexample fuel nozzle 104 of the example gas turbine engine of FIGS. 1, 2,3, and/or 4. In the illustrated example of FIG. 7, the fuel nozzle 104at least partially includes the first circuit 108 and the second circuit110. In FIG. 7, the first circuit controller 506 is in communicationwith a hydrogen gas valve 702, and a nitrogen valve 704. In FIG. 7, thenitrogen valve 704 is an example implementation of the inert gas valve604 of FIG. 6. In some alternative examples, the nitrogen valve 704and/or the inert gas valve 604 is implemented as a carbon dioxide valve.Further the second circuit controller 508 is in communication with amethane valve 706, and a water valve 708. In FIG. 7, the hydrogen gasvalve 702 and the nitrogen valve 704 are in connection with the firstcircuit 108. Further, the methane valve 706 and the water valve 708 arein connection with the second circuit 110. In some examples, thehydrogen gas valve 702, the nitrogen valve 704, the methane valve 706,and the water valve 708 are positioned between a supply and the first orsecond circuit 108, 110.

In the illustrated example of FIG. 7, the first circuit controller 506controls a position of the hydrogen gas valve 702 and the nitrogen valve704 to control a blend of hydrogen gas and nitrogen (e.g., inert gas).In some examples, the first circuit controller 506 adjusts a position ofthe hydrogen valve 702 and/or the nitrogen valve 704 to adjust acomposition of the blend of hydrogen gas and nitrogen. In theillustrated example of FIG. 7, the second circuit controller 508controls a position of the methane valve 706 and the water valve 708 toinduce water or methane into the combustor 114, as discussed inassociation with FIG. 6.

FIGS. 8A-C illustrate fluid blends that flow through an alternative fuelnozzle (e.g., a 3-circuit fuel nozzle) 800 to the combustor 114 of thegas turbine engine 100. Specifically, FIGS. 8A-C illustrate operatingphases of the blend of hydrogen gas and inert gas or other combustiblegas and the water or methane transported through the alternative fuelnozzle 800. In the illustrated example, the alternative fuel nozzle 800includes an outside circuit 802, a first inside circuit 804 positionedconcentrically within the outside circuit 802, and a second insidecircuit 806 positioned concentrically within the first inside circuit804.

FIG. 8A illustrates example fluid blends that flow through thealternative fuel nozzle 800 to start the gas turbine engine 100 andtransition to a synchronized idle speed. In FIG. 8A, the gas turbineengine 100 is started with the blend of hydrogen gas and inert gas orother combustible gas transported through the outside circuit 802 andmethane 302 transported through the first and second inside circuits804, 806. In FIG. 8A, methane 302 is implemented the blend of hydrogengas and inert gas or other combustible gas to start the gas turbineengine 100. Accordingly, methane 302 is transported through the outsidecircuit 802, the first inside circuit 804, and the second inside circuit806 to start and accelerate the gas turbine engine 100 to thesynchronized idle speed. Further, methane 302 purges the outside circuit802 before hydrogen gas is transported through the outside circuit 802.In some other examples, an inert gas, such as nitrogen or carbondioxide, purges the outside circuit 802 as methane 302 is transportedthrough the first and second inside circuits 804, 806 to accelerate thegas turbine engine 100 to the synchronized idle speed.

FIG. 8B illustrates fluid blends that flow through the alternative fuelnozzle 800 to transition the gas turbine engine 100 to operate usinghydrogen gas. In FIG. 8B, hydrogen gas is induced through the outsidecircuit 802 to provide a mixture of hydrogen gas and methane 306 to thecombustor 114. In FIG. 8B, water 304 is induced into the combustor 114through the first and second inside circuits 804, 806. In other words,the alternative fuel nozzle 800 terminates injections of methane intothe combustor 114 through the first and second inside circuits 804, 806as the gas turbine engine 100 operates by utilizing hydrogen gas as fueland water 308 as a coolant to suppress nitrogen oxide emissions, quenchcombustor 114 flame temperature, and protect hardware associated withthe combustor 114. In the illustrated example of FIG. 8B, a percentageof hydrogen gas in the mixture of hydrogen gas and methane 306 and avolumetric flow rate of water 304 simultaneously increase as a load ofthe gas turbine engine 100 increases.

FIG. 8C illustrates fluid blends that flow through the alternative fuelnozzle 800 to transition the gas turbine engine 100 to operate using100% hydrogen gas 310 as fuel. In FIG. 8C, hydrogen gas 310 istransported through the outside circuit 802 into the combustor 114. InFIG. 8C, the water 304 is transported through the first and secondinside circuits 804, 806 to the combustor 114.

FIG. 9 is a block diagram of a schematic 900 of the alternative fuelnozzle 800 of FIGS. 8A-C. In the illustrated example of FIG. 9, the fuelnozzle 800 at least partially includes the outside circuit 802, thefirst inside circuit 804, and the second inside circuit 806. In FIG. 9,the first circuit controller 506 is in communication with thealternative fuel nozzle 800, a hydrogen gas valve 902, an inert gasvalve 904, and an other combustible gas valve 906. Further, the secondcircuit controller 508 is in communication with the alternative fuelnozzle 800, a methane (e.g., natural gas) valve 908, and a water valve910. In some examples, the hydrogen gas valve 902, the inert gas valve904, and the other combustible gas valve 906 are positioned betweenrespective supplies and the outside circuit 802. In some examples, themethane valve 908 and the water valve 910 are positioned betweenrespective supplies and the first and second inside circuits 804, 806.

In the illustrated example of FIG. 9, the first circuit controller 506controls a position of the hydrogen gas valve 902, the inert gas valve904, and the other combustible gas valve 906 to control the blend ofhydrogen gas and inset gas or other combustible gas. In some examples,the first circuit controller 506 adjusts a position of the hydrogenvalve 902, the inert gas valve 904, and/or the other combustible gasvalve 906 to adjust a composition of the blend of hydrogen gas and inertgas or other combustible gas. In FIG. 9, the second circuit controller508 controls the water or methane transported through the first andsecond inside circuits 804, 806. In some examples, the second circuitcontroller 508 adjusts a position of the methane valve 908 and the watervalve 910 to transition between injecting methane or water.

While an example manner of implementing the combustor controller 102 ofFIGS. 1, 5, 6, 7, and/or 9 is illustrated in FIGS. 10 and 11, one ormore of the elements, processes and/or devices illustrated in FIGS.10-11 may be combined, divided, re-arranged, omitted, eliminated and/orimplemented in any other way. Further, the example stage manager 504,the example first circuit controller 506, the example outside circuitcontroller 508, the example other combustible gas injection processor510, the example inert gas injection processor 512, the example hydrogengas injection processor 514, the example methane injection processor516, the example water injection processor 518 and/or, more generally,the example combustor controller 102 of FIGS. 1, 5, 6, 7, and/or 9 maybe implemented by hardware, software, firmware and/or any combination ofhardware, software and/or firmware. Thus, for example, any of theexample stage manager 504, the example first circuit controller 506, theexample outside circuit controller 508, the example other combustiblegas injection processor 510, the example inert gas injection processor512, the example hydrogen gas injection processor 514, the examplemethane injection processor 516, the example water injection processor518 and/or, more generally, the example combustor controller 102 couldbe implemented by one or more analog or digital circuit(s), logiccircuits, programmable processor(s), programmable controller(s),programmable sensor(s), graphics processing unit(s) (GPU(s)), digitalsignal processor(s) (DSP(s)), application specific integrated circuit(s)(ASIC(s)), programmable logic device(s) (PLD(s)) and/or fieldprogrammable logic device(s) (FPLD(s)). When reading any of theapparatus or system claims of this patent to cover a purely softwareand/or firmware implementation, at least one of the example stagemanager 504, the example first circuit controller 506, the exampleoutside circuit controller 508, the example other combustible gasinjection processor 510, the example inert gas injection processor 512,the example hydrogen gas injection processor 514, the example methaneinjection processor 516, the example water injection processor 518is/are hereby expressly defined to include a non-transitory computerreadable storage device or storage disk such as a memory, etc. includingthe software and/or firmware. Further still, the example combustorcontroller of FIGS. 1, 5, 6, 7, and/or 9 may include one or moreelements, processes and/or devices in addition to, or instead of, thoseillustrated in FIG. 5, and/or may include more than one of any or all ofthe illustrated elements, processes and devices. As used herein, thephrase “in communication,” including variations thereof, encompassesdirect communication and/or indirect communication through one or moreintermediary components, and does not require direct physical (e.g.,wired) communication and/or constant communication, but ratheradditionally includes selective communication at periodic intervals,scheduled intervals, aperiodic intervals, and/or one-time events.

A flowchart representative of example hardware logic, machine readableinstructions, hardware implemented state machines, and/or anycombination thereof for implementing the combustor controller 102 ofFIGS. 1, 5, 6, 7, and/or 9 is shown in FIGS. 10 and 11. The machinereadable instructions may be one or more executable programs orportion(s) of an executable program for execution by a computerprocessor and/or processor circuitry, such as the processor 1212 shownin the example processor platform 1200 discussed below in connectionwith FIG. 12. The program may be embodied in software stored on anon-transitory computer readable storage medium such as a memoryassociated with the processor 1212, but the entire program and/or partsthereof could alternatively be executed by a device other than theprocessor 1212 and/or embodied in firmware or dedicated hardware.Further, although the example program is described with reference to theflowchart illustrated in FIGS. 10 and 11, many other methods ofimplementing the example combustor controller 102 may alternatively beused. For example, the order of execution of the blocks may be changed,and/or some of the blocks described may be changed, eliminated, orcombined. Additionally or alternatively, any or all of the blocks may beimplemented by one or more hardware circuits (e.g., discrete and/orintegrated analog and/or digital circuitry, an FPGA, an ASIC, acomparator, an operational-amplifier (op-amp), a logic circuit, etc.)structured to perform the corresponding operation without executingsoftware or firmware. The processor circuitry may be distributed indifferent network locations and/or local to one or more devices (e.g., amulti-core processor in a single machine, multiple processorsdistributed across a server rack, etc.).

The machine readable instructions described herein may be stored in oneor more of a compressed format, an encrypted format, a fragmentedformat, a compiled format, an executable format, a packaged format, etc.Machine readable instructions as described herein may be stored as dataor a data structure (e.g., portions of instructions, code,representations of code, etc.) that may be utilized to create,manufacture, and/or produce machine executable instructions. Forexample, the machine readable instructions may be fragmented and storedon one or more storage devices and/or computing devices (e.g., servers)located at the same or different locations of a network or collection ofnetworks (e.g., in the cloud, in edge devices, etc.). The machinereadable instructions may require one or more of installation,modification, adaptation, updating, combining, supplementing,configuring, decryption, decompression, unpacking, distribution,reassignment, compilation, etc. in order to make them directly readable,interpretable, and/or executable by a computing device and/or othermachine. For example, the machine readable instructions may be stored inmultiple parts, which are individually compressed, encrypted, and storedon separate computing devices, wherein the parts when decrypted,decompressed, and combined form a set of executable instructions thatimplement one or more functions that may together form a program such asthat described herein.

In another example, the machine readable instructions may be stored in astate in which they may be read by processor circuitry, but requireaddition of a library (e.g., a dynamic link library (DLL)), a softwaredevelopment kit (SDK), an application programming interface (API), etc.in order to execute the instructions on a particular computing device orother device. In another example, the machine readable instructions mayneed to be configured (e.g., settings stored, data input, networkaddresses recorded, etc.) before the machine readable instructionsand/or the corresponding program(s) can be executed in whole or in part.Thus, machine readable media, as used herein, may include machinereadable instructions and/or program(s) regardless of the particularformat or state of the machine readable instructions and/or program(s)when stored or otherwise at rest or in transit.

The machine readable instructions described herein can be represented byany past, present, or future instruction language, scripting language,programming language, etc. For example, the machine readableinstructions may be represented using any of the following languages: C,C++, Java, C#, Perl, Python, JavaScript, HyperText Markup Language(HTML), Structured Query Language (SQL), Swift, etc.

As mentioned above, the example processes of FIGS. 10 and 11 may beimplemented using executable instructions (e.g., computer and/or machinereadable instructions) stored on a non-transitory computer and/ormachine readable medium such as a hard disk drive, a flash memory, aread-only memory, a compact disk, a digital versatile disk, a cache, arandom-access memory and/or any other storage device or storage disk inwhich information is stored for any duration (e.g., for extended timeperiods, permanently, for brief instances, for temporarily buffering,and/or for caching of the information). As used herein, the termnon-transitory computer readable medium is expressly defined to includeany type of computer readable storage device and/or storage disk and toexclude propagating signals and to exclude transmission media.

“Including” and “comprising” (and all forms and tenses thereof) are usedherein to be open ended terms. Thus, whenever a claim employs any formof “include” or “comprise” (e.g., comprises, includes, comprising,including, having, etc.) as a preamble or within a claim recitation ofany kind, it is to be understood that additional elements, terms, etc.may be present without falling outside the scope of the correspondingclaim or recitation. As used herein, when the phrase “at least” is usedas the transition term in, for example, a preamble of a claim, it isopen-ended in the same manner as the term “comprising” and “including”are open ended. The term “and/or” when used, for example, in a form suchas A, B, and/or C refers to any combination or subset of A, B, C such as(1) A alone, (2) B alone, (3) C alone, (4) A with B, (5) A with C, (6) Bwith C, and (7) A with B and with C. As used herein in the context ofdescribing structures, components, items, objects and/or things, thephrase “at least one of A and B” is intended to refer to implementationsincluding any of (1) at least one A, (2) at least one B, and (3) atleast one A and at least one B. Similarly, as used herein in the contextof describing structures, components, items, objects and/or things, thephrase “at least one of A or B” is intended to refer to implementationsincluding any of (1) at least one A, (2) at least one B, and (3) atleast one A and at least one B. As used herein in the context ofdescribing the performance or execution of processes, instructions,actions, activities and/or steps, the phrase “at least one of A and B”is intended to refer to implementations including any of (1) at leastone A, (2) at least one B, and (3) at least one A and at least one B.Similarly, as used herein in the context of describing the performanceor execution of processes, instructions, actions, activities and/orsteps, the phrase “at least one of A or B” is intended to refer toimplementations including any of (1) at least one A, (2) at least one B,and (3) at least one A and at least one B.

As used herein, singular references (e.g., “a”, “an”, “first”, “second”,etc.) do not exclude a plurality. The term “a” or “an” entity, as usedherein, refers to one or more of that entity. The terms “a” (or “an”),“one or more”, and “at least one” can be used interchangeably herein.Furthermore, although individually listed, a plurality of means,elements or method actions may be implemented by, e.g., a single unit orprocessor. Additionally, although individual features may be included indifferent examples or claims, these may possibly be combined, and theinclusion in different examples or claims does not imply that acombination of features is not feasible and/or advantageous.

FIG. 10 is a flowchart representative of example machine-readableinstructions 1000 that can be executed to implement the combustorcontroller 102 of FIGS. 1, 5, 6, 7, and/or 9. At block 1002, thecombustor controller 102 purges the first circuit 108 of the fuel nozzle104 and the combustor 114. For example, the engine power processor 502indicates a low power level (e.g., less than 10% rated power) of the gasturbine engine 100 to the combustor controller 102 when the gas turbineengine 100 begins operating. In some examples, the stage manager 504compares the low power level to the rated power of the gas turbineengine 100 to determine the operating stage of the gas turbine engine100. In some examples, combustor controller 102 and/or stage manager 504receives a configuration of the circuit breaker 101. In some suchexamples, the combustor controller 102 and/or the stage manager 504determines that the gas turbine engine 100 is in an initial power stage(e.g., a purge stage). Further, the stage manager 504 provides a purgeindication to the first circuit controller 506. In some examples, theother combustible gas injection processor 510 and/or the inert gasinjection processor 512 of the first circuit controller 506 determinesthat an other combustible gas and/or an inert gas, respectively, is tobe injected through the first circuit 108. In some examples, thecombustor controller 102 triggers the fuel metering valve(s) 103 tocontrol the blend of at least one of hydrogen gas, inert gas, or othercombustible gas induced into the first circuit 108 and the combustor114. In some examples, the combustor controller 102 opens the inert gasvalve 604, 904 or the nitrogen valve 704 to purge the first circuit 108of the fuel nozzle 104 and the combustor 114 with the inert gas. In someexamples, the combustor controller 102 opens the other combustible gasvalve 606, 906 to purge the first circuit 108 of the fuel nozzle 104 andthe combustor 114 with the other combustible gas. Further, the othercombustible gas transported through the first circuit 108 alsoaccelerates the gas turbine engine 100 during the purge. In someexamples, purging deoxygenates and removes residual hydrogen gas fromthe combustor 114 and the first circuit 108 to prevent undesiredcombustion.

At block 1004, the combustor controller 102 synchronizes the gas turbineengine 100 to an idle speed. For example, the stage manager 504 providesan initial power stage indication to the second circuit controller 508.In some examples, the methane injection processor 516 of the secondcircuit controller 508 indicates to the combustor controller 102 thatmethane (e.g., methane 302) is to be injected into the combustor 114through the second circuit 110 of the fuel nozzle 104 based on theinitial power stage indication. In some examples, the combustorcontroller 102 triggers the fuel metering valve(s) 103 to induce methaneinto the second circuit 110 and the combustor 114. In some examples, thecombustor controller 102 opens the methane valve 608, 706, 908 to injectmethane into the second circuit 110. Further, the methane is injectedinto the combustor 114 by the fuel nozzle 104 increasing a power outputof the gas turbine engine 100. In some examples, the other combustiblegas induced into the combustor 114 through the first circuit 108increases the power output of the gas turbine engine 100 instead of, orin addition to, the methane transported through the second circuit 110

At block 1006, the combustor controller 102 injects water into thecombustor 114 through the second circuit 110. For example, the stagemanager 504 determines that the gas turbine engine 100 is operating at asynchronized idle speed when the power from the engine power processor502 is approximately 10% of the rated power of the gas turbine engine100 and/or the circuit breaker 101 of the gas turbine engine 100 isclosed to accept loads. In some examples, the stage manager 504 informsthe second circuit controller 508 that the gas turbine engine isoperating at the synchronized idle speed and/or the circuit breaker 101of the gas turbine engine 100 is closed. In some examples, the waterinjection processor 518 of the second circuit controller 508 indicatesto the combustor controller 102 that water is to be induced into thesecond circuit 110 and the combustor 114 based on the indication fromthe stage manager 504. Further, the methane injection processor 516indicates to the combustor controller 102 that injections of methanethrough the second circuit 110 are to be terminated prior to inducingwater into the second circuit 110. In some examples, the combustorcontroller 102 triggers the fuel metering valve(s) 103 to inject waterand terminate injections of methane. In some examples, the combustorcontroller 102 closes the methane valve 608, 706, 908 to terminateinjections of methane and opens the water valve 610, 708, 910 to injectwater into the second circuit 110. In other words, the second circuit110 transitions from inducing methane 302 into the combustor 114 toinducing water 304 into the combustor 114. Further, the water isinjected into the combustor 114 by the fuel nozzle 104 to provide flamemanagement and thermal protection to hardware associated with the fuelnozzle 104 and/or the combustor 114. In some examples, the waterprovides a thermal barrier between the hydrogen gas and the hardwareassociated with the fuel nozzle 104.

At block 1008, the combustor controller 102 injects hydrogen gas intothe combustor 114 through the first circuit 108. In some examples, thestage manager 504 informs the first circuit controller 506 that thecircuit breaker 101 of the gas turbine engine 100 is closed and the gasturbine engine 100 is operating at the synchronized idle speed. In someexamples, the hydrogen gas injection processor 514 of the first circuitcontroller 506 indicates to the combustor controller 102 that hydrogengas is to be induced into the first circuit 108 and the combustor 114based on the indication from the stage manager 504. In some examples,the combustor controller 102 triggers the fuel metering valve(s) 103 toinject the hydrogen gas. In some examples, the combustor controller 102opens the hydrogen gas valve 602, 702, 902 to inject the hydrogen gasinto the first circuit 108. In other words, the blend of at least one ofhydrogen gas, inert gas, or other combustible gas transitions from theother combustible gas (e.g., methane 302) or the inert gas (e.g.,nitrogen 402, carbon dioxide) to a mixture of hydrogen gas and the othercombustible gas or inert gas (e.g., the mixture of hydrogen gas andmethane 306, the mixture of nitrogen and hydrogen gas 404). Further, thehydrogen gas has a lower fuel consumption (pph), reduces carbonemissions, and provides more energy to the gas turbine engine 100 thanconventional hydrocarbons, such as methane. After the combustorcontroller 102 injects hydrogen gas into the combustor 114 through thefirst circuit 108, the machine-readable instructions 1000 proceed toblock 1010 and block 1012 approximately simultaneously.

At block 1010, the combustor controller 102 increases a volumetric flowrate of water injected through the second circuit 110 as the poweroutput (e.g., load) of the gas turbine engine 100 is maintained orincreases. In some examples, the combustor controller 102 increases thevolumetric flow rate of water injected through the second circuit 110while also increasing the percentage of hydrogen gas injected throughthe first circuit 108 (e.g., at block 1012). In some examples, theengine power processor 502 indicates the power output of the gas turbineengine 100 to the combustor controller 102. In some examples, the stagemanager 504 informs the second circuit controller 508 of the poweroutput of the gas turbine engine 100. In some examples, the waterinjection processor 518 of the second circuit controller 508 indicatesan increasing volumetric flow of water to be induced into the secondcircuit 110 and the combustor 114 to the combustor controller 102 basedon the power output of the gas turbine engine 100. Accordingly, thevolume of water injected into the second circuit 110 and the combustor114 increases to maintain a temperature of the combustor 114 as thehydrogen maintains or increases the power output of the gas turbineengine 100.

At block 1012, the combustor controller 102 increases a percentage ofhydrogen gas in the blend of at least one of hydrogen gas, inert gas, orother combustible gas injected through the first circuit 108 to up to100% hydrogen gas as the gas turbine engine 100 maintains or increasesthe power output thereof. In some examples, the combustor controller 102increases the percentage of hydrogen gas injected through the firstcircuit 108 while also increasing the volumetric flow rate of waterinjected through the second circuit 110 (e.g., at block 1010). In someexamples, the stage manager 504 informs the first circuit controller 506of the power output of the gas turbine engine 100. In some examples, thehydrogen gas injection processor 514 of the first circuit controller 506indicates an increasing volume of hydrogen gas to be induced into thefirst circuit 108 and the combustor 114 to the combustor controller 102based on the power output of the gas turbine engine 100. Accordingly,the volume of hydrogen gas induced into the first circuit 108 and thecombustor 114 increases to maintain or increase the power output of thegas turbine engine 100. Additionally, the volume of inert gas or othercombustible gas in the blend of at least one of hydrogen gas, inert gas,or other combustible gas decreases as the volume of hydrogen gasincreases. Further, the percentage of hydrogen gas in the blend of atleast one of hydrogen gas, inert gas, or other combustible gas increasesto up to 100% hydrogen gas when the gas turbine engine 100 is operatingat, or between, 10% and/or 100% of the rated power of the gas turbineengine 100. In other words, the blend of at least one of hydrogen gas,inert gas, or other combustible gas transitions from the mixture ofhydrogen gas and methane 306 or the mixture of nitrogen and hydrogen gas404 to hydrogen gas 310 when the gas turbine engine is operating at, orbetween, 10% and/or 100% rated power.

At block 1014, the engine power processor 502 determines if/when the gasturbine engine 100 is to shut down (e.g., power down). In some examples,the engine power processor 502 increases, decreases, and/or modulatesthe power output of the gas turbine engine 100 until the shutdown is tooccur. If the gas turbine engine 100 is not to shut down, themachine-readable instructions 1000 return to block 1014. If the gasturbine engine 100 is to power down, the machine-readable instructions1000 proceed to block 1016

At block 1016, the process to operate the gas turbine engine 100 with upto 100% hydrogen gas is inverted to shut down the gas turbine engine100, as discussed further in association with FIG. 11.

FIG. 11 is a flowchart representative of machine readable instructionsthat can be executed to implement a power shutdown of the example gasturbine engine 100 of FIGS. 1-9 (e.g., block 1016 of the example of FIG.10). At block 1102, the combustor controller 102 reduces a percentageand/or volume of hydrogen gas injected through the first circuit 108. Insome examples, the combustor controller 102 receives a shutdownindication from the engine power processor 502. In some examples, theengine power processor 502 reduces the power output of gas turbineengine 100 incrementally before providing the shutdown indication to thecombustor controller 102. In some examples, the stage manager 504informs the first circuit controller 506 of the shutdown. In someexamples, the hydrogen gas injection processor 514 of the first circuitcontroller 506 decreases the volume and/or percentage of hydrogen gas inthe blend of at least one of hydrogen gas, inert gas, or othercombustible gas transported through the first circuit 108. Further, thepower output of the gas turbine engine 100 decreases as the volumeand/or percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas decreases.

At block 1104, the combustor controller 102 reduces the volumetric flowrate of water injected into the combustor 114 through the second circuit110. In some examples, the combustor controller 102 reduces thevolumetric flow rate of water injected through the second circuit 110while simultaneously decreasing the percentage of hydrogen gas injectedthrough the first circuit 108 (e.g., block 1102). In some examples, thestage manager 504 informs the second circuit controller 508 of theshutdown. In some examples, the water injection processor 518 of thesecond circuit controller 508 decreases the volumetric flow rate ofwater injected into the second circuit 110 and the combustor 114 as thepower output of the gas turbine engine 100 is reduced.

At block 1106, the combustor controller 102 opens the circuit breaker101 of the gas turbine engine 100. In some examples, the combustorcontroller 102 reduces the power output of the gas turbine engine 100 toapproximately 10% of the rated power by reducing the flow of hydrogengas and water at block 1102 and block 1104. In some examples, the gasturbine engine 100 opens the circuit breaker 101 so the gas turbineengine 100 no longer accepts loads.

At block 1108, the combustor controller 102 purges the first circuit 108of the fuel nozzle 104 and the combustor 114. For example, the combustorcontroller 102 receives a purge indication from the engine powerprocessor 502 after the circuit breaker 101 opens. In some examples, thestage manager 504 of the combustor controller 102 informs the firstcircuit controller 506 of the purge. In some such examples, the inertgas injection processor 512 of the first circuit controller 506indicates to the combustor controller 102 that the inert gas (e.g.,nitrogen, carbon dioxide, etc.) is to be induced into the first circuit108 to purge the first circuit 108 and the combustor 114. Further, thecombustor controller 102 triggers the inert gas valve 604, 904 or thenitrogen valve 704 of the fuel metering valve(s) 103 to open and inducethe inert gas to purge the first circuit 108 and the combustor 114. Insome examples, purging the first circuit 108 and the combustor 114 is asafety measure that prevents undesired combustion in systems that havecommunicated hydrogen gas during operations.

At block 1110, the combustor controller 102 shuts down (e.g., powersdown) the gas turbine engine 100. For example, the engine powerprocessor 502 indicates that the combustor controller 102 is not toinject the blend of at least one of hydrogen gas, inert gas, or othercombustible gas into the first circuit 108 and the water or methane intothe second circuit 110. In some examples, the gas turbine engine 100terminates operations when the combustor controller 102 terminatesinjections of water and the blend of at least one of hydrogen gas, inertgas, or combustible gas. In some examples, an engine controller performsshuts down the gas turbine engine 100 instead.

FIG. 12 is a block diagram of an example processor platform 1100structured to execute the instructions of FIGS. 10 and 11 to implementthe combustor controller 102 of FIGS. 1, 5, 6, 7, and/or 9. Theprocessor platform 1200 can be, for example, a server, a personalcomputer, a workstation, a self-learning machine (e.g., a neuralnetwork), a mobile device (e.g., a cell phone, a smart phone, a tabletsuch as an iPad™), or any other type of computing device.

The processor platform 1200 of the illustrated example includes aprocessor 1212. The processor 1212 of the illustrated example ishardware. For example, the processor 1212 can be implemented by one ormore integrated circuits, logic circuits, microprocessors, GPUs, DSPs,or controllers from any desired family or manufacturer. The hardwareprocessor may be a semiconductor based (e.g., silicon based) device. Inthis example, the processor implements the example stage manager 504,the example first circuit controller 506, the example outside circuitcontroller 508, the example other combustible gas injection processor510, the example inert gas injection processor 512, the example hydrogengas injection processor 514, the example methane injection processor516, the example water injection processor 518 and/or, more generally,the example combustor controller 102.

The processor 1212 of the illustrated example includes a local memory1213 (e.g., a cache). The processor 1212 of the illustrated example isin communication with a main memory including a volatile memory 1214 anda non-volatile memory 1216 via a bus 1218. The volatile memory 1214 maybe implemented by Synchronous Dynamic Random Access Memory (SDRAM),Dynamic Random Access Memory (DRAM), RAMBUS® Dynamic Random AccessMemory (RDRAM®) and/or any other type of random access memory device.The non-volatile memory 1216 may be implemented by flash memory and/orany other desired type of memory device. Access to the main memory 1214,1216 is controlled by a memory controller.

The processor platform 1200 of the illustrated example also includes aninterface circuit 1220. The interface circuit 1220 may be implemented byany type of interface standard, such as an Ethernet interface, auniversal serial bus (USB), a Bluetooth® interface, a near fieldcommunication (NFC) interface, and/or a PCI express interface.

In the illustrated example, one or more input devices 1222 are connectedto the interface circuit 1220. The input device(s) 1222 permit(s) a userto enter data and/or commands into the processor 1212. The inputdevice(s) can be implemented by, for example, the example engine powerprocessor 502, an audio sensor, a microphone, a camera (still or video),a keyboard, a button, a mouse, a touchscreen, a track-pad, a trackball,isopoint, a user interface, and/or a voice recognition system.

One or more output devices 1224 are also connected to the interfacecircuit 1220 of the illustrated example. The output devices 1024 can beimplemented, for example, by the example fuel metering valve(s) 103,display devices (e.g., a light emitting diode (LED), an organic lightemitting diode (OLED), a liquid crystal display (LCD), a cathode raytube display (CRT), an in-place switching (IPS) display, a touchscreen,etc.), a tactile output device, a printer and/or speaker. The interfacecircuit 1220 of the illustrated example, thus, typically includes agraphics driver card, a graphics driver chip, and/or a graphics driverprocessor.

The interface circuit 1220 of the illustrated example also includes acommunication device such as a transmitter, a receiver, a transceiver, amodem, a residential gateway, a wireless access point, and/or a networkinterface to facilitate exchange of data with external machines (e.g.,computing devices of any kind) via a network 1226. The communication canbe via, for example, an Ethernet connection, a digital subscriber line(DSL) connection, a telephone line connection, a coaxial cable system, asatellite system, a line-of-site wireless system, a cellular telephonesystem, etc.

The processor platform 1200 of the illustrated example also includes oneor more mass storage devices 1228 for storing software and/or data.Examples of such mass storage devices 1228 include floppy disk drives,hard drive disks, compact disk drives, and redundant array ofindependent disks (RAID) systems.

The machine executable instructions 1232 (e.g., the example instructions1000 and/or 1016 of FIGS. 10 and 11, etc.) may be stored in the massstorage device 1228, in the volatile memory 1214, in the non-volatilememory 1216, and/or on a removable non-transitory computer readablestorage medium such as a CD or DVD.

From the foregoing, it will be appreciated that example methods,apparatus and articles of manufacture have been disclosed that operate agas turbine engine with up to 100% hydrogen gas as fuel. Morespecifically, the examples described herein enable a gas turbine engineto consume less fuel (pph), produce less carbon emissions, and generatea greater quantity of energy than conventional gas turbine engines.Further, the examples described herein enable a gas turbine engine toquench a temperature within a combustor, protect hardware associatedwith the combustor, and provide nitrogen oxide emissions abatement.

Example methods and apparatus to operate a gas turbine engine withhydrogen gas are disclosed herein. Further examples and combinationsthereof include the following:

1. A combustor nozzle apparatus of a gas turbine engine comprising afirst circuit to transport a blend of at least one of hydrogen gas,inert gas, or other combustible gas from a supply to a gas turbinecombustor, the blend of at least one of hydrogen gas, inert gas, orother combustible gas including between 100% hydrogen gas, 100% inertgas, or 100% other combustible gas, a second circuit to transport waterfrom the supply to the gas turbine combustor, and a nozzle tip includinga first outlet in connection with the second circuit, the first outletto provide the water to the gas turbine combustor, and a second outletin connection with the first circuit, the second outlet concentricallypositioned within the first outlet to provide the blend of at least oneof hydrogen gas, inert gas, or other combustible gas to the gas turbinecombustor.

2. The combustor nozzle apparatus of any preceding clause, wherein thefirst circuit and the gas turbine combustor are purged by at least oneof the inert gas or the other combustible gas prior to transporting thehydrogen gas.

3. The combustor nozzle apparatus of any preceding clause, wherein theinert gas is at least one of nitrogen gas, or carbon dioxide.

4. The combustor nozzle apparatus of any preceding clause, wherein theother combustible gas is at least one of methane or propane.

5. The combustor nozzle apparatus of any preceding clause, wherein apercentage of hydrogen gas increases in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas in the first circuitand simultaneously a volumetric flow rate of water increases in thesecond circuit as the gas turbine maintains or increases a power output.

6. The combustor nozzle apparatus of any preceding clause, wherein atleast one of the inert gas or the other combustible gas purges the firstcircuit and the gas turbine combustor when the gas turbine engine isshutting down.

7. The combustor nozzle apparatus of any preceding clause, wherein thewater provides the gas turbine combustor with thermal protection forhardware associated with the gas turbine combustor.

8. The combustor nozzle apparatus of any preceding clause, wherein thethermal protection includes a thermal barrier between the hydrogen gasand the hardware associated with the combustor nozzle.

9. The combustor nozzle apparatus of any preceding clause, furtherincluding a third outlet circumferentially surrounding the first outlet,the third outlet including an air swirler to provide air flow to the gasturbine combustor.

10. The combustor nozzle apparatus of any preceding clause, wherein thethird outlet of the nozzle tip includes an air swirler to mix the waterwith the blend of at least one of hydrogen gas, inert gas, or othercombustible gas.

11. The combustor nozzle apparatus of any preceding clause, wherein thefirst outlet of the nozzle tip includes a water swirler to reduce a sizeof water droplets.

12. The combustor nozzle apparatus of any preceding clause, wherein thecombustor nozzle is coupled to a case of the gas turbine engine.

13. The combustor nozzle apparatus of any preceding clause, wherein afirst mode of operation corresponds to the first circuit transportingthe hydrogen gas, and wherein a second mode of operation corresponds tothe first circuit transporting another gas other than the hydrogen gas.

14. The combustor nozzle apparatus of any preceding clause, wherein thesecond circuit transports methane from the supply to the gas turbinecombustor during the second mode of operation.

15. A method to operate a gas turbine engine with up to 100% hydrogengas as fuel including purging a gas turbine combustor and a firstcircuit of a combustor nozzle with an inert gas or an other combustiblegas, injecting hydrogen gas into the gas turbine combustor through thefirst circuit of the combustor nozzle, the first circuit including ablend of at least one of hydrogen gas, inert gas, or other combustiblegas, wherein the blend of at least one of hydrogen gas, inert gas, orother combustible gas includes between 100% hydrogen gas and 100% inertgas or 100% other combustible gas, injecting water into the gas turbinecombustor through a second circuit of the combustor nozzle, andincreasing a percentage of hydrogen gas in the blend of at least one ofhydrogen gas, inert gas, or other combustible gas to up to 100% hydrogengas as the gas turbine engine maintains or increases a power output.

16. The method of any preceding clause, further including injectingmethane into the gas turbine combustor through the second circuit of thecombustor nozzle in response to the first circuit injecting gases otherthan the hydrogen gas.

17. The method of any preceding clause, wherein a volumetric flow rateof water in the second circuit increases as the percentage of hydrogengas increases in the blend of at least one of hydrogen gas, inert gas,or other combustible gas.

18. The method of any preceding clause, further including mixing thewater with the blend of at least one of hydrogen gas, inert gas, orother combustible gas via at least one of an air swirler or a waterswirler at an outlet of the combustor nozzle.

19. The method of any preceding clause, wherein at least one of the airswirler or the water swirler quenches a temperature within the gasturbine combustor.

20. The method of any preceding clause, further including shutting downthe gas turbine engine in a case of emergency determined by comparing asupply of the hydrogen gas to a minimum threshold supply of the hydrogengas.

21. The method of any preceding clause, wherein shutting down the gasturbine engine includes decreasing the percentage of hydrogen gas in theblend of at least one of hydrogen gas, inert gas, or other combustiblegas as the gas turbine decreases the power output, decreasing avolumetric flow rate of water in the second circuit, opening a circuitbreaker of the gas turbine engine, purging the gas turbine combustor andthe first circuit of the combustor nozzle with the inert gas, andpowering down the gas turbine engine.

22. An apparatus of a gas turbine engine including a memory, and one ormore processors communicatively coupled to the memory, the memoryincluding instructions that, when executed, cause the one or moreprocessors to purge a first circuit of a combustor nozzle and a gasturbine combustor with an inert gas or an other combustible gas, injecthydrogen gas into the gas turbine combustor through the first circuit ofthe combustor nozzle, the first circuit of the nozzle including a blendof at least one of hydrogen gas, inert gas, or other combustible gas,the blend of at least one of hydrogen gas, inert gas, or othercombustible gas including between 100% hydrogen gas and 100% inert gasor 100% other combustible gas, inject water into the gas turbinecombustor through a second circuit of the combustor nozzle, and increasea percentage of hydrogen gas in the blend of at least one of hydrogengas, inert gas, or other combustible gas to up to 100% hydrogen gas asthe gas turbine engine maintains or increases a power output.

23. The apparatus of any preceding clause, wherein the instructions,when executed, cause the one or more processors to open at least one ofan inert gas valve or an other combustible gas valve to purge the firstcircuit of the combustor nozzle and the gas turbine combustor with theinert gas or other combustible gas, open a hydrogen valve to injecthydrogen gas into the gas turbine combustor through the first circuit ofthe combustor nozzle, the first circuit of the nozzle including a blendof at least one of hydrogen gas, inert gas, or other combustible gas,open a water valve to inject water into the gas turbine combustorthrough the second circuit of the combustor nozzle, and close the inertgas valve or the other combustible gas valve to increase a percentage ofhydrogen gas in the blend of at least one of hydrogen gas, inert gas, orother combustible gas, the blend of at least one of hydrogen gas, inertgas, or other combustible gas including between 100% hydrogen gas and100% inert gas or other combustible gas.

24. The apparatus of any preceding clause, wherein the instructions,when executed, cause the one or more processors to inject methane intothe gas turbine combustor through the second circuit of the combustornozzle in response to the first circuit injecting the inert gas or othercombustible gas into the gas turbine combustor.

25. The apparatus of any preceding clause, wherein the instructions,when executed, cause the one or more processors to increase a volumetricflow rate of water in the second circuit as the percentage of hydrogengas increases in the blend of at least one of hydrogen gas, inert gas,or other combustible gas.

26. The apparatus of any preceding clause, wherein the instructions,when executed, cause the one or more processors to decrease thepercentage of hydrogen gas in the blend of at least one of hydrogen gas,inert gas, or other combustible gas as the power output of the gasturbine engine decreases, decrease a volumetric flow rate of water inthe second circuit, open a circuit breaker of the gas turbine engine,purge the gas turbine combustor and the first circuit of the combustornozzle with the inert gas, and power down the gas turbine engine.

27. The apparatus of any preceding clause, wherein the instructions,when executed, cause the one or more processors to shut down the gasturbine engine based on a hydrogen gas supply.

Although certain example methods, apparatus and articles of manufacturehave been disclosed herein, the scope of coverage of this patent is notlimited thereto. On the contrary, this patent covers all methods,apparatus and articles of manufacture fairly falling within the scope ofthe claims of this patent.

The following claims are hereby incorporated into this DetailedDescription by this reference, with each claim standing on its own as aseparate embodiment of the present disclosure.

What is claimed is:
 1. A method to operate a gas turbine with up to 100%hydrogen gas as fuel comprising: injecting an other combustible gas intoa combustor; and in response to at least one of (i) a power output ofthe gas turbine satisfying a rated power threshold or (ii) an operatingfrequency of the gas turbine satisfying an operating frequencythreshold: injecting water into the combustor; injecting hydrogen intothe combustor; and terminating injections of the other combustible gas.2. The method of claim 1, further including closing a circuit breaker ofthe gas turbine in response to at least one of (i) the power output ofthe gas turbine satisfying the rated power threshold or (ii) theoperating frequency of the gas turbine satisfying the operatingfrequency threshold.
 3. The method of claim 2, wherein up to 100% of acombustion input is the hydrogen in response to the circuit breakerbeing closed.
 4. The method of claim 3, further including increasing avolumetric flow rate of the water into the combustor as a percentagecomposition of the hydrogen as the combustion input increases.
 5. Themethod of claim 1, wherein injecting the hydrogen into the combustorincludes injecting the hydrogen through a first circuit of a combustornozzle, and wherein injecting the water into the combustor includesinjecting the water through a second circuit of the combustor nozzleseparate from the first circuit.
 6. The method of claim 5, whereininjecting the other combustible gas into the combustor includesinjecting the other combustible gas through the first circuit.
 7. Themethod of claim 6, wherein terminating the injections of the othercombustible gas includes: reducing a first volumetric flow rate of theother combustible gas through the first circuit; and increasing a secondvolumetric flow rate of the hydrogen through the first circuit.
 8. Themethod of claim 5, wherein injecting the other combustible gas into thecombustor includes injecting the other combustible gas through thesecond circuit.
 9. The method of claim 8, wherein injecting the waterinto the combustor includes transitioning the second circuit fromtransporting the other combustible gas to transporting the water. 10.The method of claim 1, wherein the hydrogen is injected into thecombustor in response to the water being injected into the combustor.11. The method of claim 1, further including purging the combustor withat least one of an inert gas or the other combustible gas.
 12. Themethod of claim 1, wherein the water is injected into the combustorthrough a first outlet of a combustor nozzle, further including:inducing air into the combustor through a second outlet of the combustornozzle, the second outlet positioned around the first outlet; swirlingthe air at the first outlet via a first swirler of the combustor nozzle;and swirling the water at the second outlet via a second swirler of thecombustor nozzle.
 13. A method to operate a gas turbine with up to 100%hydrogen gas as fuel comprising: adjusting an other combustible gasvalve to a first open position to induce an other combustible gas into acombustor, the other combustible gas to be utilized as a combustingfuel; determining whether the gas turbine is operating at a synchronizedidle speed; and in response to the gas turbine operating at thesynchronized idle speed: adjusting a water valve to a second openposition to induce water into the combustor with a first volumetric flowrate; adjusting a hydrogen valve to a third open position to inducehydrogen into the combustor in response to water being injected into thecombustor; and adjusting the other combustible gas valve to a closedposition to terminate injections of the other combustible gas into thecombustor.
 14. The method of claim 13, in advance of adjusting the othercombustible gas valve to the closed position, further including:adjusting the water valve to a fourth open position, the fourth openposition more open than the second open position; and at least one of:adjusting the hydrogen valve to a fifth open position, the fifth openposition more open than the third open position; or adjusting the othercombustible gas valve to a sixth open position, the sixth open positionless open than the first open position.
 15. The method of claim 13,wherein adjusting the hydrogen valve to the third open position inducesthe hydrogen into the combustor through a first circuit of a combustornozzle, and wherein adjusting the water valve to the second openposition induces the water into the combustor through a second circuitof the combustor nozzle.
 16. The method of claim 15, wherein adjustingthe other combustible gas valve to the first open position induces theother combustible gas into the combustor through the first circuit ofthe combustor nozzle.
 17. The method of claim 13, wherein determiningthe gas turbine is operating at the synchronized idle speed includes atleast one of: determining a circuit breaker of the gas turbine isclosed; determining a power output of the gas turbine satisfies a ratedpower threshold; or determining an operating frequency of the gasturbine satisfies an operating frequency threshold.
 18. The method ofclaim 13, further including utilizing the hydrogen as 100% of thecombusting fuel in response to adjusting the other combustible gas valveto the closed position.
 19. A method to operate a gas turbine with up to100% hydrogen gas as fuel comprising: injecting an other combustible gasinto a combustor; and in response to at least one of (i) a power outputof the gas turbine satisfying a rated power threshold or (ii) anoperating frequency of the gas turbine satisfying an operating frequencythreshold: injecting water into the combustor; injecting hydrogen intothe combustor; and reducing a volumetric flow rate of the othercombustible gas.
 20. The method of claim 19, further includingterminating injections of the other combustible gas in response to thepower output of the gas turbine satisfying the rated power threshold.